EP3052435B1 - Procédé de stockage d'énergie électrique - Google Patents

Procédé de stockage d'énergie électrique Download PDF

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EP3052435B1
EP3052435B1 EP14776885.7A EP14776885A EP3052435B1 EP 3052435 B1 EP3052435 B1 EP 3052435B1 EP 14776885 A EP14776885 A EP 14776885A EP 3052435 B1 EP3052435 B1 EP 3052435B1
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methane
hydrogen
soot
gas
energy
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EP3052435A1 (fr
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Marek Fulde
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    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
    • C01B3/22—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of gaseous or liquid organic compounds
    • C01B3/24—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of gaseous or liquid organic compounds of hydrocarbons
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/0005—Reversible uptake of hydrogen by an appropriate medium, i.e. based on physical or chemical sorption phenomena or on reversible chemical reactions, e.g. for hydrogen storage purposes ; Reversible gettering of hydrogen; Reversible uptake of hydrogen by electrodes
    • C01B3/001—Reversible uptake of hydrogen by an appropriate medium, i.e. based on physical or chemical sorption phenomena or on reversible chemical reactions, e.g. for hydrogen storage purposes ; Reversible gettering of hydrogen; Reversible uptake of hydrogen by electrodes characterised by the uptaking medium; Treatment thereof
    • C01B3/0021—Carbon, e.g. active carbon, carbon nanotubes, fullerenes; Treatment thereof
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C1/00—Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon
    • C—CHEMISTRY; METALLURGY
    • C25—ELECTROLYTIC OR ELECTROPHORETIC PROCESSES; APPARATUS THEREFOR
    • C25B—ELECTROLYTIC OR ELECTROPHORETIC PROCESSES FOR THE PRODUCTION OF COMPOUNDS OR NON-METALS; APPARATUS THEREFOR
    • C25B1/00—Electrolytic production of inorganic compounds or non-metals
    • C25B1/01—Products
    • C25B1/02—Hydrogen or oxygen
    • C25B1/04—Hydrogen or oxygen by electrolysis of water
    • C—CHEMISTRY; METALLURGY
    • C25—ELECTROLYTIC OR ELECTROPHORETIC PROCESSES; APPARATUS THEREFOR
    • C25B—ELECTROLYTIC OR ELECTROPHORETIC PROCESSES FOR THE PRODUCTION OF COMPOUNDS OR NON-METALS; APPARATUS THEREFOR
    • C25B15/00—Operating or servicing cells
    • C25B15/08—Supplying or removing reactants or electrolytes; Regeneration of electrolytes
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D15/00—Adaptations of machines or engines for special use; Combinations of engines with devices driven thereby
    • F01D15/10—Adaptations for driving, or combinations with, electric generators
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K17/00—Using steam or condensate extracted or exhausted from steam engine plant
    • F01K17/06—Returning energy of steam, in exchanged form, to process, e.g. use of exhaust steam for drying solid fuel or plant
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
    • F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
    • F02C6/18—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/02—Details
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/06—Combination of fuel cells with means for production of reactants or for treatment of residues
    • H01M8/0606—Combination of fuel cells with means for production of reactants or for treatment of residues with means for production of gaseous reactants
    • H01M8/0656—Combination of fuel cells with means for production of reactants or for treatment of residues with means for production of gaseous reactants by electrochemical means
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J15/00—Systems for storing electric energy
    • H02J15/008—Systems for storing electric energy using hydrogen as energy vector
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/02—Processes for making hydrogen or synthesis gas
    • C01B2203/0266—Processes for making hydrogen or synthesis gas containing a decomposition step
    • C01B2203/0272—Processes for making hydrogen or synthesis gas containing a decomposition step containing a non-catalytic decomposition step
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/08—Methods of heating or cooling
    • C01B2203/0805—Methods of heating the process for making hydrogen or synthesis gas
    • C01B2203/0861—Methods of heating the process for making hydrogen or synthesis gas by plasma
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/12—Feeding the process for making hydrogen or synthesis gas
    • C01B2203/1205—Composition of the feed
    • C01B2203/1211—Organic compounds or organic mixtures used in the process for making hydrogen or synthesis gas
    • C01B2203/1235—Hydrocarbons
    • C01B2203/1241—Natural gas or methane
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2220/00—Application
    • F05D2220/30—Application in turbines
    • F05D2220/32—Application in turbines in gas turbines
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2220/00—Application
    • F05D2220/70—Application in combination with
    • F05D2220/72—Application in combination with a steam turbine
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2220/00—Application
    • F05D2220/70—Application in combination with
    • F05D2220/76—Application in combination with an electrical generator
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2240/00—Components
    • F05D2240/35—Combustors or associated equipment
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/14—Combined heat and power generation [CHP]
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/30—Hydrogen technology
    • Y02E60/32—Hydrogen storage
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/30—Hydrogen technology
    • Y02E60/36—Hydrogen production from non-carbon containing sources, e.g. by water electrolysis
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/30—Hydrogen technology
    • Y02E60/50—Fuel cells
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E70/00—Other energy conversion or management systems reducing GHG emissions
    • Y02E70/30—Systems combining energy storage with energy generation of non-fossil origin
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y02P20/129—Energy recovery, e.g. by cogeneration, H2recovery or pressure recovery turbines
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y02P20/133—Renewable energy sources, e.g. sunlight
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
    • Y02P90/50—Energy storage in industry with an added climate change mitigation effect

Definitions

  • the invention relates to a method for storing electrical energy by converting electrical energy into methane gas. Furthermore, the invention relates to a system for storing electrical energy.
  • Renewable energy sources such as photovoltaic or wind energy allow the production of energy, especially electricity, without the emission of harmful gases such as carbon dioxide (CO 2 ).
  • CO 2 carbon dioxide
  • fossil fuels such as oil, coal or natural gas
  • large quantities of harmful CO 2 are emitted.
  • wind and sun are not always available. Sunlight is only available during the day.
  • the availability of solar and wind energy depends on the weather conditions and the season. As a result, consumption or energy demand rarely coincides with energy production from renewable energies. After previous planning therefore conventional power plants continue to be held in order to compensate for a temporary shortage of electrical energy. A complete avoidance of CO 2 emissions is not possible.
  • adiabatic compressed air storage where compressors compress air in an oversupply of electrical energy and store it in underground caverns. The compressed air can then be used to drive turbines to generate electricity.
  • the disadvantage is that the compressed air storage can store only comparatively little electrical energy.
  • adiabatic compressed air reservoirs are only suitable for short-term storage, since the heat generated during the compression of the air can not be stored indefinitely.
  • Hydrogen is suitable as an emission-free fuel because it burns to water.
  • hydrogen is difficult to transport, so in case of storage of electric energy, the re-conversion of the hydrogen should take place at the same place.
  • offshore wind turbines fall the place of energy production and the place where the energy is needed, far apart what the power grids heavily loaded.
  • a further storage option is the production of methane gas.
  • methane gas in a Sabatier reaction of hydrogen and carbon methane gas is produced.
  • the methane gas can be introduced into the existing natural gas network, since methane is also the main component of natural gas. In this way, the energy could not only be stored, but also transported without additional load on the power grids from the power generation site to the place where the electrical energy is needed.
  • WO 2013/034130 A2 is a method of using energy from biomass known, wherein in a first phase of operation a mixture of Biomass and fossil carbon such as coal is converted into synthesis gas.
  • the synthesis gas is converted into electricity in a gas-fired power station and the carbon dioxide formed is stored in the soil or converted into methane in a second operating phase of synthesis gas with hydrogen produced from excess electrical energy by electrolysis of water.
  • the methane is stored in the gas network.
  • a method of operating a power-to-gas device is known.
  • electrical energy is used to generate hydrogen by means of electrolytes and convert together with CO 2 to methane, which can be fed into a natural gas network.
  • the CO 2 is either taken from the air or provided from a CO2 tank. It is further provided to interrupt the operation of the power-to-gas unit immediately and to disconnect them from the power grid when the grid frequency of the power grid falls below a predetermined limit. This allows the power grid to be relieved immediately.
  • the document DE 10 2009 045 564 A1 describes a desulphurisation plant which simultaneously undergoes hydrodesulfurization (HDS) and cetane elevation of naphtha.
  • the starting material for conventional liquid fuels is petroleum, which is separated by distillation into various boiling fractions. After the atmospheric distillation, the second process step in the refinery is followed by desulphurisation.
  • hydrodesulfurization is used, in which the petroleum distillate is passed over a solid, finely divided catalyst comprising a metal for hydrogenation supported by an alumina layer underlay.
  • the catalysts used are nickel-molybdenum and chromium-molybdenum contacts. In addition, copious amounts of hydrogen are included in the feed.
  • the hydrogenation reaction taking place on the catalyst leads to H 2 S and the hydrogenated hydrocarbon radical.
  • Hydrothreated Vegetable Oil (HVO) as a Renewable Diesel Fuel: Trade-off between NOx, Particulate Emission, and Fuel Consumption of a Heavy Duty Engine by H. Aatola, M. Larmi, T. Sarjovaara and S. Mikkonen, 2008 SAE International Study, 2008-01-25 00 describes the use of fuels obtained by hydrogenation of vegetable oils.
  • unsaturated vegetable oils and hydrogen are converted to fuels suitable for use in conventional internal combustion engines, wherein the hydrogen is bound in the fuel and in the combustion of the fuel for power generation.
  • a disadvantage of the prior art is in particular that on the one hand only a part of the resulting CO 2 can be separated from the combustion exhaust gas, so that the CO 2 emissions, although reduced, but can not be completely avoided. On the other hand, the separation and also the handling of the gaseous CO 2 are complicated.
  • An object of the present invention can be seen to simplify the handling of the carbon in the circulation and to avoid CO 2 emissions.
  • step c energy can be generated by reacting the methane in soot and water in a cyclic bromination-oxidation process.
  • the soot accumulated in the cyclic bromination-oxidation process is then collected and re-run through the methane production process Step a) used. Also in this case, a closed carbon cycle is created.
  • the carbon (soot) is thus not used in the proposed method as a fuel for energy production, but serves as a carrier for the hydrogen.
  • power generation both the power generation and the use of the obtained by cleavage of methane in step c) hydrogen for other energy applications such as heating, cooling or for the operation of means of transport such as cars, trucks, trains or ships are considered.
  • buildings can be heated or cooled with the energy generated.
  • the methane is generated in a stream methane conversion plant using a Sabatier reaction.
  • water (H 2 O) is split into electrons (H 2 ) and oxygen (O 2 ) by electrolysis.
  • the water is preferably heated to about 90 ° C before electrolysis using process steam.
  • the high-temperature steam electrolysis HotElly
  • the electrolysis products hydrogen and oxygen are initially stored in buffer tanks.
  • methanation is commenced.
  • soot is removed from a warehouse, predried in a dryer and reacted with the electrolysis products in methane.
  • the carbon black is burned after drying to carbon dioxide (CO 2 ).
  • CO 2 carbon dioxide
  • the oxygen used in the electrolysis is preferably used. If the oxygen used in the combustion is used, the effectiveness of the method is increased compared to the use of air, since then no separation of the nitrogen contained in the air requires methane produced.
  • the energy released during combustion in the form of heat can be taken from the CO 2 gas with a steam generator.
  • the steam can be used as process steam and / or for power generation.
  • the generated CO 2 is then added to the hydrogen obtained in the electrolysis, with an optimum for the Sabatier reaction ratio between carbon dioxide and hydrogen is set.
  • Optimal here is a stoichiometric (1: 4) to slightly more than stoichiometric ratio based on hydrogen.
  • the gas mixture then flows into a hydrogenation plant, where it is reacted on a catalyst at elevated pressure in the range of about 8 to 30 bar (0.8 to 3.0 MPa), preferably in the range of about 8 to 10 bar to methane becomes.
  • the carbon black is fed to a gasification plant after drying. There it is reacted at a temperature between 900 ° C and 1800 ° C, preferably between 1200 and 1800 ° C, under the action of oxygen and water vapor in synthesis gas. Particularly preferably, the temperature in the reaction is about 1500 ° C.
  • the heat released during the reaction of the soot to the synthesis gas can be taken off with a steam generator and used as process steam.
  • the synthesis gas is added to the hydrogen from the electrolysis, wherein an optimal ratio for the hydrogenation reaction between carbon monoxide from the synthesis gas and hydrogen is adjusted.
  • Optimal here is a stoichiometric (1: 3) to slightly more than stoichiometric ratio based on hydrogen.
  • the gas mixture then flows into a hydrogenation plant, where the synthesis gas is reacted on a catalyst in methane, with CO + 3H 2 to CH 4 + H 2 O reacts. Again, the heat released in the hydrogenation reaction can be removed with a steam generator and used as process steam.
  • the solid bed is brought to the operating temperature by burning the unreacted carbon black in a parallel reaction stage.
  • oxygen from the water electrolysis is used.
  • Combustion gases are admixed to the methane-carbon oxide mixture and cooled to a temperature in the range of 200 to 250 ° C.
  • the dissipated heat can be used to produce electrical power.
  • the methanation of the remaining carbon oxides is carried out. Again, the stoichiometric ratio is adjusted by adding the hydrogen obtained by electrolysis. The waste heat of the exothermic methanation reaction is used to generate electricity or as district heating.
  • the methane produced may still contain carbon dioxide residues. These are separated in a carbon dioxide separator and fed back to the methanation reaction. Polyimide hollow fiber membranes can be used to separate the carbon dioxide.
  • the methane gas is now dried and compressed. Furthermore, the methane gas is adjusted, so that the permissible for the supply to the gas network hydrogen content (H 2 ) is maintained. Subsequently, the methane gas can be fed into the public natural gas grid for storage according to step b) of the method. Alternatively, it is also conceivable to store the methane gas in a pressure vessel.
  • the generated methane gas may be used in step c) of the power generation process in a methane-to-electricity conversion plant.
  • the methane gas is first preheated in a heat exchanger using process heat.
  • the methane gas is fed to a plasma hydrogen generator.
  • the methane is split into carbon (soot) and gaseous hydrogen.
  • the plasma is generated for example by irradiation of microwaves.
  • the plasma splitting of the methane takes place at relatively low temperatures between about 400 to 600 ° C, so that thermal losses are minimized.
  • the soot is separated from the hydrogen.
  • the conversion of the methane into hydrogen and carbon black takes place with a yield of about 96 to 97%.
  • Other methods suitable for the production of hydrogen from methane such as the "Channel Black” or the “Degussa Black” (also known to those skilled in the art as gas soot Degussa processes) may be used, although these work with less effectiveness.
  • the methane gas is thermally split.
  • a methane gas / air mixture is fed to a burner consisting of several small burner cap.
  • the resulting small flames strike against a water-cooled rotating roller, where a part of the soot is deposited. The remainder is separated from the gas phase in a downstream filter unit.
  • the further soot treatment or use of the air / hydrogen mixture is carried out analogously to the plasma process already described.
  • methane-to-electricity conversion equipment operating on the basis of a cyclic bromination-oxidation process may be used to produce energy from the methane.
  • the process involves two exothermic reaction steps. In a first step, methane is reacted with bromine with elimination of carbon black in hydrogen bromide. In a second step, hydrogen bromide is oxidized to water, whereby the bromine is released and reused.
  • the separated carbon black is agglomerated in a granulation apparatus and cooled.
  • a granulation device for example, a drum granulator can be used.
  • a downstream dryer dries the soot before it is stored in a store. From the storage, the soot can then be loaded onto a suitable means of transport to be returned to the stream methane conversion plant. The soot may then be used in re-running the methane production process.
  • the hydrogen released from the methane can now be used to generate energy.
  • the hydrogen can be mixed with combustion air and burned in a gas turbine.
  • the gas turbine drives a power generator that generates electrical power.
  • the exhaust gases from the combustion can be used via a steam generator to generate process steam.
  • the process steam can then be used to dry the soot and / or to preheat the methane gas.
  • the stream methane conversion plant and the methane stream conversion plant are spatially separated, with the methane being transported via the public gas grid. In this way it is possible to produce the methane gas in the vicinity of the power generator and to convert the methane gas into electrical power in the vicinity of the energy consumers.
  • heat produced is at least partially fed into a district heating network.
  • the efficiency of the systems can be increased.
  • the electric current required in the current-methane conversion is generated regeneratively.
  • electric power from wind power and solar systems is suitable because in these systems, the production is dependent on the weather conditions and the season and is not adapted to the needs of energy consumers. Excess energy that can not be removed at the moment can then be used to produce methane.
  • a system comprising a power-methane conversion plant, wherein electric power is converted into methane together with soot and water, and a methane-power conversion plant, wherein methane is converted into hydrogen with elimination of soot and then into electric power wherein means are provided for returning the soot from the methane-to-electricity conversion plant to the stream-methane conversion plant.
  • means are provided for catching, agglomerating and drying the soot.
  • the soot is stored in a store and can be loaded from there into a means of transport such as a truck or a railway wagon.
  • means are provided for filling the soot from the transport means into a reservoir.
  • the soot can then be used to produce methane.
  • the current-methane conversion plant and the methane-electricity conversion plant carry out the process described so that the carbon is circulated.
  • the carbon is returned in solid form, which allows easy handling.
  • carbon is not used as an energy source, but as a carrier for hydrogen.
  • the carbon is thereby fed once to the process and is then circulated. Emissions of CO 2 or other greenhouse gases do not occur.
  • the hydrogen needed for energy production is recovered in the proposed process using electricity from renewable energy sources such as wind and solar. These already deliver large amounts of electrical energy when the wind or sun is available, but these can often not be used or "consumed”. This excess energy can now be converted into methane with the proposed method, the methane gas being stored in the public natural gas grid.
  • the natural gas network can absorb large quantities of gas even with a slight increase in pressure.
  • the natural gas network also allows transport over long distances, so that the back conversion of methane gas into electricity can be done in the vicinity of the consumer. This relieves the power grids considerably as much of the renewable energy, e.g. Offshore wind power plants, far away from consumers of energy is generated.
  • the stored energy can also be taken in the form of hydrogen with the proposed method, which can be used for example for refueling of hydrogen-powered vehicles.
  • the carbon is guided in an easy-to-use cycle.
  • the resulting in the methane decomposition soot can be completely separated from the Wasserstroff and stored without much effort.
  • the transport and handling of solid carbon are associated with less effort than the handling of gaseous CO 2 .
  • FIG. 1 shows a schematic of the proposed method for storing electrical energy.
  • Electricity-to-methane conversion plant 90 draws electrical energy from power grid 10 when there is an oversupply of electricity from renewable energy sources.
  • the renewable energy may in particular be wind energy 12 or solar energy 14, but also come from other sources 16 such as hydropower.
  • the electric current is used in the current-to-methane conversion plant 90 in order to split by means of electrolysis 18 of water H 2 O into hydrogen H 2 and oxygen O 2 .
  • the oxygen O 2 is converted together with carbon black C from a carbon black storage 30 and water in a coal gasification unit 20 to synthesis gas containing carbon dioxide CO 2 , carbon monoxide CO and hydrogen H 2 .
  • synthesis gas containing carbon dioxide CO 2 , carbon monoxide CO and hydrogen H 2 .
  • Both in the combustion, as well as when converting to synthesis gas heat is released which is used for preheating the water H 2 O, which is the electrolysis 18 is supplied.
  • the heat can be used to generate electricity, wherein the generated electric current via a connection 36 can also be used for the electrolysis 18.
  • the generated electric current via a connection 36 can also be used for the electrolysis 18.
  • the resulting from the coal gasification unit 20 synthesis gas or carbon dioxide is then entered together with the hydrogen H 2 from the electrolysis 18 in the methanation 22. There, methane gas is produced in a Sabatier reaction or a hydrogenation reaction. This is compressed and freed of remaining carbon dioxide in the public gas network 24 is fed, which serves as a gas storage 26.
  • methane gas is taken from the gas network 24 and fed into the methane-to-electricity conversion plant 92. There, the methane gas is split by a hydrogen generator 28 in hydrogen H 2 and carbon black C. The soot C is supplied to the storage 30 where it is available for a renewed methane conversion.
  • the hydrogen H 2 from the hydrogen generator 28 is now input to a gas power plant 32 which burns it and produces electrical power. The generated electrical current is now fed back into the power grid 10.
  • the carbon used here is completely recycled, this being in solid form between the methane-to-electricity conversion plant 92, the Carbon storage 30 and the power methane conversion system 90 is transported. A complex separation of carbon dioxide from combustion exhaust gases and the transport of gaseous carbon dioxide are thus avoided.
  • FIG. 2 shows a schematic of a first embodiment of a stream-methane conversion plant.
  • a stream methane conversion plant 90 is shown schematically.
  • the plant comprises five sections.
  • the electrolysis is carried out. Electric power is removed from the power grid 10 and fed to a water electrolyzer 40.
  • the electrolyzer 40 splits water H 2 O, which is heated by means of process steam in a heat exchanger 60 to about 90 ° C, in hydrogen H 2 and oxygen O 2 .
  • the electrolysis products are stored in each case in a hydrogen tank 42 and an oxygen tank 44. If sufficient quantities of hydrogen and oxygen are available, methane production will commence.
  • soot C is removed at a delivery point 78 and entered into a carbon storage 30. From the carbon reservoir 30, the soot C is removed and fed to a dryer 46. The soot C is input from the oxygen tank 44 into a carbon gasification unit 48 together with oxygen O 2 . The oxygen is preheated via a heat exchanger 60 in the second section 102.
  • the soot is converted into synthesis gas.
  • the carbon black and the preheated oxygen react at a temperature between 900 and 1800 ° C, preferably between 1200 and 1800 ° C, under the action of water vapor in the carbon gasification unit 48 to synthesis gas.
  • the temperature in the reaction is about 1500 ° C.
  • the heat released during the reaction of the carbon black to the synthesis gas can be taken off with a steam generator 52 and used as process steam.
  • the process steam is conducted via a heat pipe 80 to a heat exchanger 60, which heats water before it enters the electrolyzer 40. It is also possible to use part of the process steam for power generation in a current generator 62.
  • the generated Electric power can be fed into the power grid 10 and used for electrolysis.
  • the synthesis gas is added with the hydrogen from the electrolysis, whereby an optimal ratio for the hydrogenation reaction between carbon monoxide from the synthesis gas and hydrogen is set.
  • Optimal is a stoichiometric (1: 3) to slightly more than stoichiometric ratio based on hydrogen.
  • the gas mixture then flows into a hydrogenation unit 54 in the fourth section 106, where the synthesis gas is reacted on a catalyst in methane, with CO + 3H 2 reacting to CH 4 + H 2 O.
  • the heat released in the hydrogenation reaction can be removed with a steam generator 52 and used as process steam.
  • the heat is conducted via a heat pipe 80 to a heat exchanger 60 which heats the oxygen prior to entering the carbon gasification unit 48.
  • Another heat exchanger 60 pre-heats the hydrogen prior to mixing with the synthesis gas.
  • the methane gas is cooled.
  • the methane gas is passed through a carbon dioxide separation 56.
  • CO 2 remaining in the methane gas is separated, for example, by means of polyimide hollow-fiber membranes and fed back into the methanation process.
  • the CO 2 is returned to the carbon gasification 48 together with the oxygen O 2 .
  • the methane gas is then compressed via a methane compressor 58. Resulting heat is removed via a further heat exchanger 60 before the methane gas is fed into the public gas network 24.
  • the gas network 24 serves here as a transport medium and on the other as gas storage.
  • Process heat which is not needed to preheat the water, hydrogen or oxygen, can be fed via a further heat exchanger 60 into a district heating network 76 and continue to be used.
  • FIG. 3 shows a schematic of another embodiment of a power-methane conversion plant.
  • FIG. 3 a second embodiment of a current-methane conversion system 90 is shown schematically.
  • the plant again comprises five sections.
  • the electrolysis is carried out. Electric power is removed from the power grid 10 and fed to a water electrolyzer 40.
  • the electrolyzer 40 splits water H 2 O, which is heated by means of process steam in a heat exchanger 60 to about 90 ° C, in hydrogen H 2 and oxygen O 2 .
  • the electrolysis products are stored in each case in a hydrogen tank 42 and an oxygen tank 44. If sufficient quantities of hydrogen and oxygen are available, methane production will commence.
  • soot C is removed at a delivery point 78 and entered into a carbon storage 30. From the carbon reservoir 30, the soot C is removed and fed to a dryer 46. The soot C is input from the oxygen tank 44 into a carbon gasification unit 48 together with oxygen O 2 .
  • the soot is burned together with the oxygen O 2 from the electrolysis to carbon dioxide CO 2 .
  • the oxygen is preheated via a heat exchanger 60.
  • the released during the combustion of soot C heat can be removed with a steam generator 52 and used as process steam.
  • the process steam can be led to the Riessrockner 46. It is also possible to use part of the process steam for power generation in a power generator 62.
  • the generated electrical current can be fed into the power grid 10 and used for electrolysis.
  • the generated CO 2 is then added in the fourth section 106 of the hydrogen obtained in the electrolysis, wherein an optimum for the Sabatier reaction ratio between carbon dioxide and hydrogen is set.
  • Optimal is a stoichiometric (1: 4) to slightly more than stoichiometric ratio based on hydrogen.
  • the gas mixture then flows into a hydrogenation plant 54, where it is converted to methane on a catalyst.
  • the process steam is conducted via a heat pipe 80 to the heat exchanger 60 in order to introduce water to preheat the entry into the electrolyzer 40. Via a further heat exchanger 60, the hydrogen is heated before mixing with the carbon dioxide.
  • the methane gas is passed through a carbon dioxide separation 56.
  • CO 2 remaining in the methane gas is separated, for example, by means of polyimide hollow-fiber membranes and fed back into the methanation process.
  • the CO 2 is returned to the hydrogenation plant 54 together with the hydrogen H 2 from the electrolysis.
  • the methane gas is then compressed via a methane compressor 58. Resulting heat is removed via a further heat exchanger 60 before the methane gas is fed into the public gas network 24.
  • Process heat which is not needed to preheat the water, hydrogen or oxygen, can be fed via a further heat exchanger 60 into a district heating network 76 and continue to be used.
  • FIG. 4 shows a schematic of a third embodiment of a stream-methane conversion plant.
  • FIG. 4 schematically represented current-methane conversion system 90 can be divided into five sections as the two previous embodiments.
  • the electrolysis is carried out.
  • the operating parameters and technical design do not differ from the two previously described embodiments.
  • soot C is taken out at a delivery point 78 and entered into a carbon store 30. From there, the soot C is removed and transported to the hydro-gasification plant 118. Drying of carbon black C is not required.
  • soot is fed to a hydro gasifier 118 along with hydrogen and steam.
  • the gas mixture is fluidized there to a temperature in the range of 700 to 800 ° C preheated sand.
  • the sand represents a solid bed.
  • the H 2 -H 2 O-soot mixture is converted to methane CH 4 and carbon dioxide CO 2 .
  • the ratio of the products CH 4 : CO 2 is about 1: 1.
  • the product gases and part of the sand bed are discharged from the apparatus.
  • Sand is separated in the cyclone 120 and fed to the regenerator 119.
  • soot in the reactor 118 is not fully reacted, it is fed to the regenerator 119 along with sand.
  • the soot is burned by the oxygen from the reservoir 44.
  • sand is also fluidized. Regenerated sand is separated in another cyclone 120 and returned to the reactor 118.
  • the combustion gases are mixed with reaction products and additional hydrogen from the tank 42, so that an optimum ratio between carbon dioxide and hydrogen of 1: 4 is set.
  • the mixture is cooled to the optimum temperature for the subsequent methanation.
  • the waste heat is used for steam generation and power generation. Power is applied internally for operating compressors 58 but also for water electrolysis 40.
  • the conversion of the carbon dioxide to methane on a catalyst takes place in a hydrogenation plant 54.
  • the catalyst can be subdivided into several, for example two, sections. Between the sections, the heat of reaction is removed to increase the yield.
  • a reactor cascade may be used for the same purpose. A portion of the reaction gas mixture is circulated for this purpose by means of a blower 59 in a circle.
  • the water vapor H 2 O (g) produced in the downstream steam generator 52 is converted into electricity and used for electrolysis in the electrolyzer 40.
  • the by-product water H 2 O (I) is first separated in a separator 81 by condensation from the gas mixture. Subsequently, as described above to the first and second embodiments, the methane gas for feeding into the public gas network 24 is prepared.
  • FIG. 5 shows a schematic of a methane-to-electricity conversion plant.
  • a methane-to-electricity conversion plant 92 is shown.
  • methane gas is taken from the gas network 24.
  • a heat exchanger 60 the methane gas is preheated and then in entered a plasma hydrogen generator 64.
  • a plasma is generated by means of microwave radiation, which comprises methane gas at a temperature between about 400 and 600 ° C into carbon (soot) and hydrogen H 2 splits.
  • Hydrogen and carbon are removed from the plasma hydrogen generator 64 and separated from each other in the second section 112 on a soot filter 66.
  • the soot is agglomerated in a granulator 68. This can be performed for example as a drum granulator.
  • the soot is dried in a dryer 46 before it is transported into a carbon reservoir 30. From there, the soot can be removed via a loading device 79 in a suitable transport container.
  • the return transport to the electricity-methane conversion plant can take place, for example, by truck or railway wagon.
  • the separated hydrogen is intermediately stored in the third section 114 in a hydrogen tank 42 before being converted into electricity in the fourth section 116.
  • the hydrogen H 2 is mixed with air 82 and then burned in a hydrogen turbine 72.
  • a power generator 62 generates electrical power from the hot combustion exhaust gases which can be fed into the power grid 10. A portion of the electrical energy generated is needed by the conversion plant itself for the operation of the plasma hydrogen generator 64 and passed over the power line 36.
  • the heat produced during the combustion of the hydrogen can be used via a steam generator 52 as process heat.
  • the generated steam can be used, for example, to preheat the methane gas. It is also possible to feed part of the heat into a district heating network 76.
  • a methane-to-electricity conversion plant operating on the basis of a cyclic bromination-oxidation process may be used.
  • heat is first produced by means of the cyclic bromination-oxidation process. This can be used to generate electricity and / or fed into a district heating network.
  • a thermal process such as e.g. the gas soot Degussa method can be used.

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Claims (10)

  1. Procédé pour la production de méthane avec utilisation d'énergie électrique et production consécutive d'énergie, comprenant les étapes de
    a) production de méthane à partir d'eau et de suie avec utilisation d'énergie électrique,
    b) accumulation du méthane,
    c) dissociation du méthane en hydrogène et en suie, l'hydrogène étant utilisé pour la production d'énergie ou production d'énergie par transformation du méthane en suie et eau dans un procédé de bromuration-oxydation cyclique,
    caractérisé en ce que la suie obtenue lors de la dissociation du méthane ou du procédé de bromuration-oxydation cyclique selon l'étape c) est récupérée et utilisée lors d'un nouveau déroulement du procédé pour la production de méthane dans l'étape a), de telle sorte qu'un circuit fermé de carbone se forme.
  2. Procédé selon la revendication 1, caractérisé en ce que la production du méthane a lieu via une réaction de Sabatier ou via une réaction d'hydrogénation.
  3. Procédé selon la revendication 2, caractérisé en ce que l'hydrogène nécessaire lors de la réaction de Sabatier ou de la réaction d'hydrogénation est obtenue par électrolyse de l'eau.
  4. Procédé selon la revendication 2 ou 3, caractérisé en ce que la suie pour la réalisation de la réaction de Sabatier est brûlée en dioxyde de carbone ou la suie est transformée sous action d'oxygène et de vapeur d'eau en gaz de synthèse, l'oxygène étant obtenu par électrolyse de l'eau.
  5. Procédé selon l'une quelconque des revendications 1 à 4, caractérisé en ce que l'accumulation du méthane est réalisée par injection dans un réseau de gaz (24).
  6. Procédé selon l'une quelconque des revendications 1 à 5, caractérisé en ce que la dissociation du méthane et la production d'énergie selon l'étape c) sont réalisées en un autre site que celui de la production du méthane selon l'étape a).
  7. Procédé selon l'une quelconque des revendications 1 à 6, caractérisé en ce que pour la production d'énergie selon l'étape c) du procédé, l'hydrogène obtenu est transformé en énergie électrique dans une pile à combustible, l'hydrogène est utilisé pour le chauffage, l'hydrogène est utilisé pour le refroidissement, l'hydrogène sert de carburant pour un moyen de transport ou l'hydrogène est utilisé pour une combinaison d'au moins deux des objectifs mentionnés.
  8. Procédé selon l'une quelconque des revendications 1 à 7, caractérisé en ce que la chaleur obtenue lors de la production de méthane selon l'étape a) et/ou lors de la production d'énergie selon de l'étape c) est injectée dans un réseau de chauffage collectif (76).
  9. Procédé selon l'une quelconque des revendications 1 à 8, caractérisé en ce que l'énergie électrique utilisée dans l'étape a) est produite par régénération.
  10. Procédé selon la revendication 9, caractérisé en ce que l'énergie électrique est produite par une installation éolienne (12) ou solaire (14).
EP14776885.7A 2013-09-30 2014-09-29 Procédé de stockage d'énergie électrique Active EP3052435B1 (fr)

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